Abstract: A method for sampling and measuring a hydrogen concentration of a gas in a subsurface formation includes boring a hole in the subsurface formation using a drill string. A gas probe is coupled to a lower end of the drill string. The method also includes opening the gas probe to collect the gas from the subsurface formation. The method also includes drawing the gas up through the drill string after the gas probe is opened. The method also includes measuring the hydrogen concentration of the gas after the gas is drawn up.

Abstract: A controller for use with a remote downhole tool is provided. The controller includes a processor and a transmitter for transmission of control signals to the remote downhole tool. The controller is configured for use at surface or uphole of the remote downhole tool to control transmission of data from the remote downhole tool. The controller is configured to transmit a control signal to the remote downhole tool to configure the remote downhole tool for transmission of data from the remote downhole tool according to a schedule or on demand. A communication system for use in a downhole environment is also provided. Methods of managing data transmission of a remote downhole tool are also provided.

Abstract: A visual inspection system intended for inspection of the difficult to reach lateral wellhead ports and annulus is provided. The inspection of the annular ports is carried out prior to running a simplified annulus intervention system. The imaging assembly of the visual inspection system of the present invention can be manoeuvred to view and capture images of remote, inaccessible, difficult to reach locations in the lateral access port and the adjacent annular region, prior to running of annulus intervention system, thus enhancing the success rate of carrying out annulus interventions and increasing safety by increasing the efficiency of well intervention operations and reducing the risk of unintended incidents.

Abstract: A tubing assembly for use in a wellbore is provided. The tubing assembly includes tubing configured to be run in a wellbore to recover downhole fluid from a formation; and at least one gauge positioned at least partially inside the tubing. The gauge is configured to detect a parameter inside the tubing.

Abstract: A method of transmitting an electrical signal between a downhole device and a surface location is provided, the method including unwinding a flexible hose from a reel at the surface location and deploying the hose down a wellbore, wherein the downhole device is attached at a downhole end of the flexible hose, providing a conductive fluid inside the flexible hose as an electrical path, and transmitting the electrical signal through the conductive fluid from one of the downhole device and the surface location to the other of the downhole device and the surface location.

Abstract: A downhole electrical power generation device is provided that includes at least one magnetic element, an electrically conductive element, and a member configured to be positioned within downhole fluid and to vibrate when the downhole fluid flows across a surface of the member. One of the magnetic element and the electrically conductive element is positioned on the member, and the other is configured to be positioned such that the electrically conductive element is located in a magnetic field produced by the at least one magnetic element to generate electrical power on vibration of the member. A method of generating electrical power downhole is further provided.

Abstract: A subsurface safety valve that includes an assembly configured to convert rotary motion from an electrically controlled drive into linear motion of a member. The member is configured to actuate a valve and to decompress an elastic member upon loss of a signal to the electrically controlled drive, and to compress the elastic member when the electrically controlled drive receives a signal.

Abstract: Valve assemblies are disclosed for use in the oil and gas industry. A disclosed valve assembly includes a housing having a bore; a valve member arranged within the housing which is movable relative to the bore between open and closed positions. The valve member includes a cutting feature and a sealing surface; a cutting component that cooperates with the cutting feature when the valve member is in moved to the closed position; a first seal element arranged within the housing and providing a first seal relative to the sealing surface; and a second seal element arranged within the housing and providing a second seal relative to the sealing surface. The second seal element is movable relative to the housing bore between first and second positions. A corresponding method of controlling communication along a bore of a housing is also disclosed.

Abstract: In described examples, there are methods and systems for communicating data signals in wells. The methods and systems may facilitate communication of data signals, for example, from an open-hole section of a well, or in a well having a discontinuous metallic well structure.

Abstract: A well bore fluid sensor is provided that includes an inner plate, a plurality of outer plates, first and second cable fixtures, and an electronics module. The inner plate defines a sensor interior cavity. The outer plates include a first outer plate and a second outer plate. The electronics module includes a resonant circuit and a power supply and is in signal communication with the inner plate and at least one of the first and second cable fixtures. The inner plate, the first and second outer plates, and the first and second cable fixtures are coupled together to form a unitary structure. The inner plate is electrically insulated from the first and second outer plates, the first and second cable fixtures. The first and second outer plates are electrically insulated from one another. The inner plate is capacitively coupled to the first and second outer plates.

Abstract: A method and system of opportunistic communication in a well structure are provided. The method includes identifying at a first location an existing signal propagating in a section of the well structure between the first location and a second location; modifying that existing signal so as to encode information at the first location for opportunistic communication of that information to the second location; and receiving the modified signal at the second location and decoding the signal so as to retrieve the information.

Abstract: A downhole injector apparatus for injecting a taggant into a wellbore includes an injector nozzle outlet and a taggant reservoir in fluid communication with the injector nozzle outlet and configured to hold the taggant to be injected. The apparatus further includes a pressure wave generator configured to apply a pressure wave within the reservoir to expel the taggant from the reservoir through the injector nozzle outlet.

Abstract: A gauge apparatus includes a body member, one or more gauge arms biased outwardly from the body member for engagement with a wall of the elongated space, and one or more deformable regions. The gauge apparatus is configured so that a variation in an outward extension of each gauge arm from the body member induces a change in strain in a corresponding one of the one or more deformable regions. A gauge system includes the gauge apparatus and an optical fiber attached to the gauge apparatus so that a strain in each deformable region of the gauge apparatus is transferred to a corresponding sensor portion of the optical fiber. The gauge system may be used for making real-time measurements of a geometry of an elongated space such as a wellbore of an oil and gas well.

Abstract: An apparatus for use in a downhole tool is provided. The apparatus includes a membrane configured to isolate an internal environment of the downhole tool from one or more further environments, internal and/or external to the downhole tool; and an electrical element configured to conduct an electrical current. The electrical element is positioned with respect to the membrane such that energy generated by the electrical current passing through the electrical element is incident on the membrane. The membrane is configured to be weakened and/or ruptured when the energy is incident thereon to allow fluid communication between the internal environment and the further environment.

Abstract: A deployable electrical contact device is provided that includes a body portion and a mounting arrangement. The mounting arrangement is controllably deployable from the body portion. The mounting arrangement is configured to retain the device at a position at a metallic well structure by mechanically engaging with a wall surface of the metallic well structure. The mounting arrangement includes electrically conductive pads configured to provide electrical continuity between the engaged metallic well structure and the mounting arrangement. The device is configured such that when deployed an electrical signal path between one or more of the conductive pads and the body portion is established to provide electrical continuity between the metallic well structure and the body portion.

Abstract: There are described devices and methods for use, for example, with signaling in a well, e.g. using a well structure of the well. Such signaling may include the communication of power and/or data signals. The devices and methods used may assist with efficient and/or effective communication of such signals. In some examples, there is described deployable devices and methods, e.g. a deployable device for signaling contact in a well, and methods associated therewith.

Abstract: A control system automatically operates a subsea well control device on detecting that a load in an Intervention Riser System (IRS) coupled to the subsea well control device has reached a threshold. The control system has a first control unit to detect that the load in the IRS has reached the threshold and a second control unit triggering actuation of the subsea well control device. The first control unit is in communication with the second control unit and issues an activation command to the second control unit to cause it to trigger actuation of the subsea well control device. The first control unit automatically issues the activation command to the second control unit upon detecting that the load in the IRS has reached the threshold, to trigger actuation of the subsea well control device prior to structural failure of an IRS.

Abstract: A hydraulic protection system for preventing collapse of a hydraulic line is provided. The system includes a pressure sensing assembly which is arranged to monitor a pressure differential between fluid external to and fluid contained within the hydraulic line; a pressure compensation assembly adapted to be coupled to the hydraulic line. In the event of a loss of pressure in the hydraulic line occurring, the pressure compensation assembly employs the pressure of the fluid external to the hydraulic line to increase the pressure of the fluid contained within the hydraulic line. The system is arranged so that the pressure compensation assembly is operated when the pressure differential monitored by the pressure sensing assembly reaches a predetermined level, which is below a collapse pressure of the hydraulic line, so that exposure of the hydraulic line to the collapse pressure is avoided.

Abstract: A valve assembly for controlling fluid communication along a well tubular that includes hydraulically operated valve that includes a valve member movable between open and closed positions, and a hydraulic actuator for moving the valve member; a control system for selectively controlling the flow of hydraulic fluid to and from the actuator; a vent chamber for selectively receiving hydraulic fluid exhausted from the actuator when the valve member is moved to its closed position; and a vent conduit for selectively receiving hydraulic fluid exhausted from the actuator when the valve member is moved to its closed position. The control system has a first valve closing state in which the vent chamber is isolated from the actuator. The control system has a second valve closing state in which fluid exhausted from the actuator during movement of the valve member to its closed position is vented into the vent chamber.

Abstract: A subsea test tree assembly is provided which includes at least one subsea test tree or SSTT, the SSTT including a valve having at least one of a cutting function and a sealing function, the valve being movable between an open position and a closed position via hydraulic fluid supplied to the valve through control lines; and a control system including a source of hydraulic fluid, the control system being arranged to supply hydraulic fluid from the source of hydraulic fluid to the valve of the at least one SSTT on detecting that the control lines have been sheared, to automatically move the valve to the closed position. A method of controlling a well using an SSTT assembly is also provided.